Multiphase Flow Meter for Testing Heavy Oil Wells Offshore Brazil

Maizeret, Pierre David; Rocha, Paulo Roberto Ribeiro; Marsili, Marcelo Danemberg; Ferreira, Igor de Almeida; Lipovetsky, Tatiana; Junior, Ewaldo Schubert; Goncalves, Edelwis; Theuveny, Bertrand

doi:10.2118/171111-ms

Cited by 6 publications

References 4 publications

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Testing a Heavy Oil Well in Ultra Deep Waters: Challenges Overcome by the State of Art Technology in Atlanta Project, Santos Basin, Brazil

Pedroso¹,

Monteiro²,

Marsili³

et al. 2015

SPE Annual Technical Conference and Exhibition

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Testing heavy oil in offshore wells is, by itself, a challenge. But testing heavy oil, highly viscous (220 cP at the reservoir temperature), in ultradeep waters (1550 m), in a horizontal well equipped with a long open hole horizontal gravel pack (800m), using an electrical submersible pump (ESP) deployed in a slant section at 75 degrees is really a big challenge. Atlanta is a post-salt oil field located 185 km off the coast of Rio de Janeiro. The field was discovered in 2001. The appraisal plan, started at the same year, included a deviated well to test the eocenic sandstones. A cased hole gravel pack was installed. The 90m interval tested, showed an unconsolidated sandstone, with high porosity (35%) and high permeability (5D). However, the oil is heavy and viscous (14° API and 228 cP in reservoir conditions), very acidic (TAN=9.8). In 2006, a long horizontal well was drilled to validate the field development concept and evaluate the potential of this kind of well construction. However, crucial problems were faced in the drilling and completion phase, which included, directional control problems, massive fluid loss in the reservoir section, use of a LCM pill, premature screen during the open hole gravel pack operation, leaving a SAS completion. Even after these problems, it was decided to maintain the well test. An ESP was run in the DST string. After some flow (approximately 20 h), the screens were plugged resulting in their failure and therefore sand/solid production. The ESP locked with the produced solids and overheated, getting burned. The partially conclusive DST showed a severe damaged well, with high skin of 40. The well was abandoned without carrying out its objectives, and the horizontal completion was not fully evaluated. The bad experience compromised the reliability of the project. However, in 2012, another operator decided to revisit the lower completion and testing procedures. After considering technology improvements and the lessons learned in the past operations, an extensive testing program was stablished and carefully executed. In 2013 a well was drilled, completed and successfully tested, with the ESP near the top of the reservoir. The zero skin completion and high productivity of the well encouraged the operator to drill and test the second well, this time using the ESP above the sea bed, inside the drilling riser, which included more difficulties due to the low temperature at that position. This paper presents the main challenges and details on how they were overcome by the successful completion and testing of the first two production wells encouraging to move on to the next phase.

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Testing a Heavy Oil Well in Ultra Deep Waters: Challenges Overcome by the State of Art Technology in Atlanta Project, Santos Basin, Brazil

Pedroso¹,

Monteiro²,

Marsili³

et al. 2015

SPE Annual Technical Conference and Exhibition

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Real-Time Surface and Downhole Measurements and Analysis for Optimizing Production

González

Chokshi

Lane

2015

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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Permanent surface and downhole measurement technologies have advanced considerably in terms of availability, reliability, performance and costs, and are increasingly deployed for real-time monitoring of wells and equipment. Permanent downhole sensors are used to measure pressure, temperature, flow rates, fluid phases and to reflect operating conditions in wellbores. Surface sensor systems provide real-time measurements of pressure, temperature, fluid phases and flow rates that need to be integrated for analysis. The resulting large volume of data has created challenges in data management, evaluation and analysis. It is important that production analysts have access to workflows and tools that provide real-time efficient and effective visualization and analysis. The optimal approach is to perform the visualization and analysis of data in real time, or near real time, to provide analysts with actionable information for timely and accurate decision making. Permanent downhole gauges are used for monitoring reservoir drainage, injection efficiency, well-completion hardware performance, and downhole pump performance. Some of the resulting benefits include reduced operational costs, improved safety, and properly monitored well integrity. Several onshore and offshore case studies are discussed to demonstrate application of real-time measurements coupled with visualization and analysis techniques to also achieve improved artificial lift performance, reduced operating costs, and manage production. The value of the information obtained from downhole permanent gauges and surface measurements are justified as evidenced by the growing number of operators relying on real-time permanent gauges. This paper reviews technologies that are used to monitor and manage equipment and production in oil and gas wells. It explains that the realized value of permanent monitoring depends on an efficient workflow for collection, evaluation, and analysis.

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Acquiring Accurate Reservoir Data During TCP To Maximize Oil Production and Increase ESP Run Life

Shumakov

Hollaender

Sarac

et al. 2018

Day 2 Thu, November 29, 2018

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Impulse testing using a simple drillstem testing (DST) or tubing-conveyed perforating (TCP) string is reinvigorated by employing a bidirectional wireless acoustic telemetry system. Paired with enhanced-functionality downhole test tools, the innovative approach reduces the cost of testing while providing critical data for completion design, reservoir monitoring and electric submersible pump (ESP) sizing. Over 46% of all the reported premature pump failures today are associated with incorrect equipment selection and pump sizing. It is mainly due to a lack of reliable reservoir information and especially in new wells without any historical production data (Vandevier, 2010).Operating the pump outside its specified range due to incorrect sizing can cause either a severe downthrust or upthrust condition that results in premature wear of the pump stages and reduces the expected life. It is mainly associated with incorrect pump sizing due to a lack of reliable reservoir information. The oil industry has long sought improvements in performing reservoir characterisation and acquiring dynamic reservoir and well data necessary for ESP sizing, especially in new wells without historical production data. The proposed new methodology and a unique impulse testing technique allow acquiring reservoir data for proper pump sizing. The impulse testing is not a new concept that allows testing the wells using a simple DST or TCP strings with no flow of hydrocarbon at the surface. This allows the cost to be reduced in comparison with conventional DST operations or any other testing methods. A new impulse testing technique uses bi-directional wireless acoustic telemetry system to acquire real-time bottom hole pressure data and interface with remote-controllable new-generation downhole tools, such as a tester valve, circulating valve, firing head, or fluid sampler, to issue commands and verify tool status. The acquired data credibly represent reservoir pressure, fluid properties, and well inflow performance that can be used for proper pump sizing.

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Multiphase Flow Meter for Testing Heavy Oil Wells Offshore Brazil

Cited by 6 publications

References 4 publications

Testing a Heavy Oil Well in Ultra Deep Waters: Challenges Overcome by the State of Art Technology in Atlanta Project, Santos Basin, Brazil

Testing a Heavy Oil Well in Ultra Deep Waters: Challenges Overcome by the State of Art Technology in Atlanta Project, Santos Basin, Brazil

Real-Time Surface and Downhole Measurements and Analysis for Optimizing Production

Acquiring Accurate Reservoir Data During TCP To Maximize Oil Production and Increase ESP Run Life

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